Method to predict overpressure uncertainty from normal compaction trendline uncertainty

ABSTRACT

A method for predicting a pressure window for drilling a borehole in a formation includes: obtaining a pore pressure related data value of the formation using a data acquisition tool; predicting pore pressure uncertainty from the pore pressure related data value of the formation using a processor; estimating uncertainty of a pressure window for drilling fluid using the predicted pore pressure uncertainty using a processor; and applying the estimated uncertainty to the pressure window to provide a modified pressure window using a processor.

BACKGROUND

Geologic formations are used for many purposes such as hydrocarbonproduction, geothermal production and carbon dioxide sequestration.Boreholes are typically drilled into the earth in order to access theformations. Prior to a borehole being drilled, forces or loads in therock mass of a formation are substantially in equilibrium with eachother. Keeping the drilled formation stable generally requires a supportpressure be applied by drilling mud in the borehole. The proper supportpressure is related to the pressure of the formation fluid in the poresof the formation (i.e., pore pressure). If the applied support pressureis insufficient, the formation surrounding the borehole may becomeunstable and collapse into the borehole damaging equipment and causingcostly delays, or formation fluid may enter into the wellbore causing akick or even a blowout.

During drilling, the pressure of the drilling mud is maintained within apressure window, for instance by a mud program. It is important that thepressure window is accurately determined in order to efficiently drillthe borehole and prevent damage. Hence, it would be well received in thedrilling industry if estimates of pore pressure were provided with anuncertainty that could be used as input to the mud program in order forthe pressure window to compensate for the uncertainty. In particular, itwould be well received if the pore pressure and associated uncertaintycould be predicted ahead of the drill bit, i.e., before the formation isdrilled.

BRIEF SUMMARY

Disclosed is a method for predicting a pressure window for drilling aborehole in a formation The method includes: obtaining a pore pressurerelated data value of the formation using a data acquisition tool;predicting pore pressure uncertainty from the pore pressure related datavalue of the formation using a processor; estimating uncertainty of apressure window for drilling fluid using the predicted pore pressureuncertainty using a processor; and applying the estimated uncertainty tothe pressure window to provide a modified pressure window using aprocessor.

Also disclosed is an apparatus for predicting a pore pressure window fordrilling a borehole in a formation. The apparatus includes a dataacquisition tool configured to perform formation measurements related topore pressure of the formation at a plurality of depths in the boreholeand a processor in communication with the downhole tool. The processoris configured to implement a method comprising at least one of thesteps: obtaining a pore pressure related data value of the formationfrom the data acquisition tool; predicting pore pressure uncertaintyfrom the pore pressure related data value of the formation; estimatinguncertainty of a pressure window for drilling fluid using the predictedpore pressure uncertainty; and applying the estimated uncertainty to thepressure window to provide a modified pressure window.

BRIEF DESCRIPTION OF THE DRAWINGS

The following descriptions should not be considered limiting in any way.With reference to the accompanying drawings, like elements are numberedalike:

FIG. 1 illustrates an exemplary embodiment of a downhole porosity tooldisposed in a borehole penetrating the earth;

FIG. 2 illustrates an exemplary pressure window for drilling operations;

FIG. 3 presents a flow chart depicting aspects of a method forestimating formation pore pressure and an associated uncertainty;

FIG. 4 depicts aspects of one approach for estimating formation porepressure and an associated uncertainty;

FIG. 5 depicts aspects of another approach for estimating formation porepressure and an associated uncertainty;

FIGS. 6A and 6B, collectively referred to as FIG. 6, depict aspects ofnomenclature of an algorithm to calculate pore pressure uncertainty formvariations of the normal compaction trendline as demonstrated on anacoustic log;

FIGS. 7A, 7B, and 7C, collectively referred to as FIG. 7, depict aspectsof first and second methods for establishing uncertainty trendlines;

FIG. 8 depicts aspects of q-factor derived from the increasingdifference between the maximum and minimum uncertainty trendlinesdeveloped from the first method for resistivity and acoustic data fromvarious regions throughout the world;

FIG. 9 depicts aspects of q-factor derived from the increasingdifference between the maximum and minimum uncertainty trendlinesdeveloped from the second method for resistivity and acoustic data fromvarious regions throughout the world;

FIG. 10 depicts aspects of pore pressure uncertainty versus q-factor foracoustic log data obtained from the Asia-Pacific region;

FIG. 11 depicts aspects of pore pressure uncertainty versus q-factor forresistivity log data obtained from the Asia-Pacific region;

FIG. 12 depicts aspects of pore pressure uncertainty versus q-factor foracoustic log data obtained from the Gulf of Mexico region;

FIG. 13 depicts aspects of pore pressure uncertainty versus q-factor forresistivity log data obtained from the Gulf of Mexico region;

FIG. 14 depicts aspects of pore pressure uncertainty versus q-factor forresistivity log data obtained from the North Sea region; and

FIG. 15 is a flow chart for a method for determining a pressure windowfor drilling a borehole.

DETAILED DESCRIPTION

A detailed description of one or more embodiments of the disclosedapparatus and method presented herein by way of exemplification and notlimitation with reference to the Figures.

FIG. 1 illustrates an exemplary embodiment of a bottom hole assembly(BHA) 9 disposed in a borehole 2 penetrating the earth 3, which includesan earth formation 4. The BHA 9 is conveyed through the borehole 2 by adrill string 5 for logging-while-drilling and/or steering applications.The drill string may represent any drill tubular for drilling a boreholesuch as coiled tubing drill pipes, or other equipment known in the art.A drill bit 6 is disposed at the distal end of the BHA 9 for drillingthe borehole 2. The BHA and the drill bit together may be referred to asa drilling tool. A drill rig 17 rotates the drill string 5 to drill theborehole 2 and pumps drilling fluid 18 through the drill string 5 inorder to lubricate the drill bit 6 and flush cuttings from the borehole2. A drilling fluid pump 7 is configured to pump the drilling fluid 18at a selected pressure or flow rate that may be controlled by acontroller. A flow sensor 8 configured to sense the flow rate of thedrilling fluid 18 may provide input to the controller for feedbackcontrol. Pressure in the borehole annulus may also be controlled by aflow control valve 19, which is configured to control the flow of thedrilling fluid 18 exiting the borehole 2. The flow control valve 19 mayalso be controller by the controller. A downhole tool 10 is disposed at(i.e., in or on) the BHA 9 and configured to perform measurements of theformation 4 at various depths to produce a measurement log. In one ormore embodiments, the downhole formation measurements are related to thepore pressure of the formation 4. That is the pore pressure of theformation 4 can be deduced absolutely or relatively from thosemeasurements. Non-limiting embodiments of those formation measurementsinclude gamma ray measurements, resistivity measurements, dielectricmeasurements, acoustic measurements, nuclear magnetic resonancemeasurements, pulsed neutron measurements, and density and/or porositymeasurements using a radiation source. In addition, in one or moreembodiments, one or more downhole tools 10 may be configured todiscriminate or identify the presence of shale in the formation 4 bynatural gamma-ray logging in order to apply the methods disclosedherein.

Still referring to FIG. 1, a downhole electronic unit 11 is disposed inthe BHA 9. The downhole electronic unit 11 is configured to operate thedownhole tool 10 and/or process measurement data. In one or moreembodiments, raw or processed measurement data can be transmitted to acomputer processing system 12 disposed at the surface of the earth 3 viaa telemetry system 13. The telemetry system 13 can be wired drill pipe14, electromagnetic telemetry, acoustic telemetry, mud pulses or mudwaves for real time communications as non-limiting examples. Dataprocessing functions can be performed by the downhole electronic unit11, the computer processing system 12 or some combination of both. Inone or more embodiments, the computer processing system 12 is configuredto be the controller that controls the drilling fluid pump 7 and/or theflow control valve 19.

The downhole electronic unit 11 and/or the computer processing system 12includes a processor for executing algorithms that partly or completelyimplement a method for estimating the pore pressure of the formation 4as a function of depth or time and an associated statistical ordeterministic parameter such as an absolute or relative standarddeviation, variance, minimum and maximum values, one or moments of afrequency distribution of a part of the data set or any other parameterto quantify the uncertainty of the pore pressure estimation. The porepressure and its uncertainty parameter may then be provided to a mudprogram for maintaining the drilling fluid pressure within the pressurewindow.

The drilling pressure window is depicted in FIG. 2 and is the acceptablerange of pressures established in the borehole annulus along the openhole section. Although not required, FIG. 2 shows the pressure gradientsinstead of the pressures as it is commonly known in the industry.Factors that are part of establishing the drilling pressure includedrilling fluid weight (or mud weight) and flow rate of the drillingfluid. In one or more embodiments, the flow rate may be determined bythe speed or output pressure of the drilling fluid pump and/or by theposition of a valve through which drilling fluid exits the borehole,sometimes referred to as managed pressure drilling. The pressure windowis defined by its upper and lower bounds. The upper bound of thepressure window is the fracture gradient. There are two lower bounds ofthe pressure window. One lower bound is the pore pressure gradient whilethe other lower bound is the collapse gradient. The pressure window isbelow the upper bound and above the highest of the two lower bounds. Forsome established methods, the pore pressure gradient is an input-factorfor determining the fracture gradient and the collapse gradient. Hence,pore pressure gradient uncertainty is an input to determining fracturegradient uncertainty, and collapse gradient uncertainty and, thus, todetermining the drilling pressure window uncertainty. In one or moreembodiments, the drilling pressure window uncertainty reduces thedrilling pressure window by the amount of the uncertainty.

Appropriate drilling is realized as long as the downhole annularpressure prevailing along the open hole section is maintained within thepressure window. In FIG. 2, equivalent descriptions for the downholeannular pressure are the mud weight (or equivalent static density, ESD)for flow-off (non-circulating) conditions, and the equivalentcirculating density (ECD) for circulating conditions.

If the downhole annular pressure prevailing along the open hole sectionof a borehole exceeds the fracture gradient, fractures are created atthe borehole wall which eventually propagate further into the formation.Drilling fluid then penetrates into these drilling-induced fracturescausing losses of drilling fluid. If the downhole annular pressure fallsbelow the pore pressure gradient, formation fluid unintentionally entersinto the borehole which is referred to as a kick. If the kick becomesuncontrollable, a blowout may occur. If the downhole annular pressurefalls below the collapse gradient, the re-distributed stresses aroundthe wellbore may exceed the compressive strength of the formation rockcausing a collapse of the wellbore wall which can result in washouts,breakouts or even total collapse of the borehole. This disclosurediscusses the pore pressure gradient in detail, but the other twopressure window bounds are also affected.

Before the pore pressure uncertainty method is discussed in detail,certain terms related to sedimentary compaction are presented. Porepressure in the underground can be hydrostatic, overpressured, orunderpressured compared to hydrostatic conditions, and differentmechanisms exist that can cause a deviation of the pore pressure fromhydrostatic. One such mechanism is based on the compaction ofsedimentary material which is transported into sedimentary basins.Compaction is referred to as the decrease of porosity of fine or coarsesedimentary material due to burial of the settled material eventuallywith addition of further material.

Under normal conditions, fluid existing in the pore space in thesedimentary material will be squeezed out of the material, so that theporosity of the sediment will decrease with increasing load from above.This mechanism of normal compaction results in a hydrostatic porepressure distribution. Assuming that compaction is the main porepressure generating mechanism, overpressure (also referred to asundercompaction) is generated whenever fluid within the pore space istrapped with continuous burial of the sediment.

During the drilling operation, the compaction trend of sediments can bemonitored for instance by inspection of pore pressure related logs(i.e., logs influenced by pore pressure) or drilling curves. Logs can bethe resistivity, dielectric permittivity, acoustic slowness of theformation, bulk density, neutron porosity, gamma ray, nuclear magneticresonance or others. A drilling curve example is the drilling exponent(DXC).

Using the resistivity log as an example, an overpressure zone isindicated by a decrease in resistivity from what would be expected in anormal compaction zone (i.e., a trend of an increase in resistivity withincreasing depth as porosity decreases). Within the spirit of thisinvention, the term porosity is not limited to pores within theformation, but to any type of void space including fractures, etc. Inone or more embodiments, the disclosed techniques for estimating porepressure and associated uncertainty are applied only to shale in shalecontaining formations. Hence, in these embodiments, the pore pressurerelated formation measurements are filtered to exclude measurementsperformed on non-shale portions of the formation.

If undercompaction is the main overpressure generating mechanism, onestep in the pore pressure modeling workflow might be the determinationof the normal compaction trendline which describes the change inporosity with depth under normal compaction conditions. A deviationbetween the normal compaction trendline and acquired porosity-indicatingdata can be used to calculate the deviation from normal pressureregimes.

The normal compaction trendline is defined by establishing a line in aplot of pore pressure related logs versus depth. This step is typicallyperformed manually. An alternative which will be explained later in moredetail is performing a linear regression (using a processor) over thenormally compacted depth interval. However, the regression conductedover different intervals will give different trendlines, depending onthe variability of the pore pressure related logs. For example, acousticslowness logs were noted to be much smoother in the normal compactionzone compared to formation resistivity logs. Note that the othervariables such as OBG, PP_(n), and the Eaton exponent (x) (which arediscussed below) are also affected by some uncertainty, and that theuncertainty of the pore pressure related log depends on the measurementprecision.

Reference may now be had to FIG. 3 which presents a flow chart depictingaspects of a method 20 for determining pore pressure and pore pressureuncertainty as a function of depth. Step 21 in method 20 calls forconveying a carrier coupled to the downhole tool 10 through a borehole.Step 22 calls for performing formation measurements using the downholetool 10 to obtain a log of formation measurements related to porepressure.

Step 23 calls for defining a first or upper depth interval and a secondor lower depth interval that is deeper in the borehole than the upperdepth interval. Each depth interval includes at least one formationmeasurement made within those intervals. Step 24 calls for establishinga plurality of compaction trendlines extending from the upper depthinterval to the lower depth interval and beyond. Each trendline isdefined by a unique set of measurement points with one measurement pointbeing in the upper depth interval and one measurement point being in thelower depth interval. Each trendline may be parameterized by a slope andan intercept. While the trendlines may be linear, they may also follow acurved function such as exponential functions or polynomial functions.Alternatively, steps 23 and 24 may be performed with all data valuescoming from one single interval (e.g., the complete normal compactionzone).

Various ways may be employed to establish a plurality of trendlines. Oneway is to determine a set of points (i.e., one point in the upper depthinterval and one point in the lower depth interval) that establishes afirst trendline having a minimum slope and minimum intercept and a setof points that establishes a second trendline having a maximum slope andmaximum intercept from all sets of points in the upper and lower depthintervals. The upper and lower depth intervals may be predefined orselected according to techniques disclosed in U.S. patent applicationSer. No. 13/229,212, which is incorporated by reference in its entirety.Alternatively, the first trendline may be established having a minimumslope and maximum intercept and the second trendline may be establishedhaving a maximum slope and minimum intercept. In general, thecombination providing the widest spread in values may be selected toprovide the basis for representing the most likely associateduncertainty. Another way of establishing a plurality of trendlinesinvolves generating trendlines through every combination or set ofmeasurement points in the upper and lower depth intervals. Othertechniques to establish the plurality of trendlines may be obtained fromU.S. patent application Ser. No. 13/229,212.

The dependence of the attributes of the calculated normal compactiontrendline on the log variability has been used to calculate a series oftrendlines over different depth intervals by an algorithm describedabove. The normal compaction trendline may be calculated automaticallyor semi-automatically using a processor or may be manually entered intoa processor. The series of trendlines can then be used to calculate anaverage normal compaction trendline and the uncertainty associated withthe average trendline. Different definitions are proposed for theuncertainty. One definition (Method 1) is the standard deviation for theaverage slope and intercept of all the determined trendlines. Anotherdefinition (Method 2) is the maximum and minimum slope determined out ofall determined trendlines.

Because there may be many trendlines, such as in the hundreds or eventhousands, it may not be possible to illustrate all of them on one plot.In cases like this, one or more trendlines with associated uncertaintymay be plotted as a representation of all the trendlines. Track 1 inFIG. 4 shows an example of a pore pressure related log, which is in thiscase a porosity-indicating resistivity log, overlain by an averagenormal compaction trendline. The trendline fits the porosity-indicatinglog in the normal compaction interval and starts deviating from theporosity-indicating log in the overpressure zone. The average trendlineis bounded by trendlines signifying +/− one standard deviation (+/−1 s).FIG. 4 Track 1 was developed using Method 1. FIG. 5 Track 3 is anexample of representing all the trendlines by plotting the maximum andminimum slope determined out of all the trendlines using Method 2. InFIGS. 4 and 5, the resistivity axis is logarithmically scaled, however,other scaling including linear scaling can be used as well.

These two methods to define a representative trendline and arepresentative value for the variation of the trendlines will beexplained in more detail. For both methods, two intervals need to bedefined from which the series of trendlines are generated: a startinterval containing i=1 . . . n data points and an end intervalcontaining j=1 . . . m data points (see FIG. 6A for nomenclature). Inone or more embodiments, both intervals reside in the normal compactionzone, although this is not required. As a first step, a regressionanalysis is performed over the interval beginning at the first datapoint from the start interval (i=1) and ending at the first data pointfrom the end interval (j=1), yielding the trendline TL_(1,1). Thistrendline may be in the normal compaction zone although it does not haveto be. Step n of the analysis defines the interval for linear regressionfrom data point i=n to j=1, giving TL_(n,1). The final linear regressionanalysis is performed for i=n, j=m to obtain trendline TL_(n,m) (seeStep n*m in 6B). This approach gives a series of n*m trendlines.

Histograms 1 and 2 in FIG. 4 illustrate the spread in slope values andintercept values (assuming linear regression which is not a requirement)of a series of trendlines as calculated according to the procedureexplained above, respectively. By assuming more parameters in thetrendline and defining more intervals, the same method may be appliedresulting in trendlines with more curvature. The distribution of theparameters derived from the series of normal compaction trendlines maybe further used as input for other pore pressure uncertainty calculatingapproaches. These approaches may include for example error propagationlaws, simulations, and neural networks. For example, Monte CarloSimulations use a parameter distribution as input assigned to themodeling parameters. In Monte-Carlo simulation applied to pore pressuremodeling, the modeling approach is first defined such as using one ofEquations (1)-(6). Using Equation (1) as an example, inputdata/parameters used to calculate the pore pressure are the overburdengradient (OBG), the resistivity log R₀, the hydrostatic pore pressurePPN and the “normal resistivity value” R_(N), which is the resistivitycorresponding to the normal compaction trendline. The resistivity log R₀is determined from actual resistivity measurements. Deviations of R₀from R_(N) may result from an overpressure condition. For a Monte-CarloSimulation, each of these input parameters is not an exact value butrepresented by a probability distribution. For example, OBG may rangefrom 12-14 ppg with its most likely value at 13 ppg. Likewise, thenormal compaction trendline is not a straight line (defined by its slopeand intercept) anymore, but a series of trendlines defined by aprobability distribution of slopes and intercepts. Then, in Monte CarloSimulation the necessary input data are randomly selected (with valueswithin the distribution or parameter range) and a pore pressure model iscalculated. This procedure is repeated a large number of times (forexample 10000 times or more) so that a series of pore pressure models iscreated with a certain probability distribution. Hence, the distributionof slopes and intercepts described above may be used as input for aMonte-Carlo simulation.

Step 25 in method 20 calls for calculating a pore pressure line (i.e., arepresentative, c.f. most likely estimate of pore pressure as a functionof depth) and associated uncertainty using the plurality of trendlines.Various methods are known in the art for converting porosity to porepressure. One method is referred to as Eaton's method. Eaton's methodcan be used with resistivity logs, conductivity logs, acoustic velocitylogs, acoustic slowness logs, or drilling exponent data. Equations(1)-(5) list various forms of equations in Eaton's method forcalculating pore pressure (PP) depending on the type of log used tomeasure porosity. Eaton's method uses the overburden gradient as aninput to the method. The overburden gradient is determined usingestablished techniques (e.g., integration of density logs) and is shownin Track 2 in FIG. 4 and Track 4 in FIG. 5.

$\begin{matrix}{{PP} = {{OBG} - {\left( {{OBG} - {PP}_{N}} \right)\left( \frac{R_{0}}{R_{N}} \right)^{x}}}} & (1) \\{{PP} = {{OBG} - {\left( {{OBG} - {PP}_{N}} \right)\left( \frac{V_{0}}{V_{N}} \right)^{x}}}} & (2) \\{{PP} = {{OBG} - {\left( {{OBG} - {PP}_{N}} \right)\left( \frac{{DT}_{N}}{{DT}_{0}} \right)^{x}}}} & (3) \\{{PP} = {{OBG} - {\left( {{OBG} - {PP}_{N}} \right)\left( \frac{C_{N}}{C_{O}} \right)^{x}}}} & (4) \\{{PP} = {{OBG} - {\left( {{OBG} - {PP}_{N}} \right)\left( \frac{{DXC}_{0}}{{DXC}_{N}} \right)^{x}}}} & (5)\end{matrix}$

In the above equations:Default value of Eaton exponent x in equation (1) is 1.2;Default value of Eaton exponent x in equations (2) and (3) is 3;OBG=overburden gradient (ppg, kPa/m, or g/cm³);PP_(N)=normal (i.e., hydrostatic conditions) pore pressure gradient(ppg, kPa/m, or g/cm³);R₀=observed resistivity (Ωm);R_(N)=“normal” (expected) resistivity (Ωm);V₀=observed interval seismic or acoustic velocity (m/s or ft/s);V_(N)=“normal” (expected) interval seismic or acoustic velocity (m/s orft/s);DT₀=observed transit time (μs/ft);DT_(N)=“normal” (expected) transit time (μs/ft);C₀=observed conductivity (S/m);C_(N)=“normal” (expected) conductivity (S/m);DXC₀=observed DXC; andDXC_(N)=“normal” (expected) DXCwhere “normal” means the value taken from the normal compactiontrendline.

As with establishing the plurality of trendlines, there are a number ofways to determine the pore pressure line, which represents pore pressureas a function of depth, and an associated uncertainty. In one wayillustrated in Track 3 in FIG. 5, a representative trendline iscalculated from the first trendline having the minimum slope and thesecond trendline having a maximum slope. The representative trendlinecan be an average of the two trendlines in one embodiment. It can beappreciated that other mathematical techniques can be used to determinethe representative trendline such as calculating a mean trendline. Theuncertainty associated with the average trendline is the spread betweenthe first trendline and the second trendline.

Once the representative trendline is calculated, Eaton's method can beapplied to determine the pore pressure gradient log (i.e., therepresentative pore pressure gradient log). Similarly, Eaton's methodcan be applied to the first trendline and the second trendline todetermine the spread of values or uncertainty about the pore pressuregradient log. Other methods may also be used to determine therepresentative pore pressure gradient log such as Gaussian errorpropagation and using only the upper and lower limits calculated byEaton's method while representative trendline is the average of theupper and lower limits. Further, methods disclosed in U.S. applicationSer. No. 13/229,212 may be used to determine the spread of uncertaintyabout the pore pressure gradient log.

An alternative method for calculating the pore pressure is theequivalent depth method which also uses the normal compaction trendlineas an input parameter. The method assumes that every depth point in anoverpressured shale interval has a corresponding (equivalent) point inthe normally compacted interval above on the normal compaction trendline. Both points have the same porosity (as indicated by an identicalresistivity, acoustic, or drilling exponent value) and thus yield thesame effective stress. Knowing the overburden and hydrostatic gradient,pore pressure can be determined as given by:

$\begin{matrix}{{PP} = \frac{{{PP}_{N} \cdot D_{1}} + \left( {{{OBG}_{2} \cdot D_{2}} - {{OBG}_{1} \cdot D_{1}}} \right)}{D_{2}}} & (6)\end{matrix}$

With D₁ and D₂ being the upper and lower depth, respectively, and OBG₁and OBG₂ the overburden gradient at the respective depth points.

When the plurality of trendlines involves generating trendlines throughevery combination of measurement points in the upper and lower depthintervals, two approaches may be used to determine the pore pressureline and associated uncertainty. In the first approach, Eaton's methodusing constant parameters is applied to each trendline in the pluralityof trendlines to generate a plurality of corresponding pore pressurelines. The representative pore pressure line, such as an average porepressure line for example, is then calculated from the plurality of porepressure lines. A statistical method is then applied to the plurality ofpore pressure lines to calculate the standard deviation of the pluralityof pore pressure lines. The standard deviation is one example of theuncertainty associated with the representative or calculated porepressure line.

In the second approach, Eaton's method using a random varying parametersuch as Eaton's exponent is applied to each trendline in the pluralityof trendlines to generate a plurality of corresponding pore pressurelines. As in the first approach, the pore pressure line can becalculated as an average of the plurality of corresponding pore pressurelines. Similarly, a statistical method is then applied to the pluralityof pore pressure lines to calculate the standard deviation of theplurality of pore pressure lines where the standard deviation representsthe uncertainty. This approach is illustrated in Tracks 1 and 2 in FIG.4 with Histogram 3 illustrating the distribution of the Eaton exponents.

It can be appreciated that certain mathematical techniques other thancalculating an average may be used to determine the calculated porepressure line. In one or more embodiments, a mean value may becalculated. It can also be appreciated that certain statisticaltechniques other than calculating the standard deviation may be used tocalculate the uncertainty associated with the calculated the porepressure line.

It can be appreciated that as the borehole 2 is drilled deeper into theearth 3 in a real time LWD application the second depth interval can becontinuously shifted deeper into the earth 3 or widened so that thelower part of the interval extends deeper into the borehole 2. Inaddition, the first depth interval may also be shifted or widened deeperinto the borehole 2. As the depth intervals are shifted or widened,these new intervals are continuously populated with formationmeasurements performed within these intervals. In one or moreembodiments, the second depth interval maintains a constant length andis continuously shifted to be at the deepest point of the drilling runup to where the normal compaction trend ends. In one or moreembodiments, the depth intervals are changed with drilling such as tomaintain a predefined ratio of the lengths of the depth intervals to thetotal drilling depth (e.g., the lengths of the depth intervals aremaintained at 0.1 times the total drilling depth). In one or moreembodiments, the upper depth interval and the upper point of the lowerdepth interval remain fixed while the lower point of the lower depthinterval is continuously moved deeper in the borehole. It can beappreciated that there are many approaches to shift or widen the depthintervals either continuously as the borehole is being drilled or atcertain time or drilling distance intervals and that these additionalapproaches are inherently included in this disclosure.

It can be appreciated that as the depth intervals are shifted orwidened, the steps of the method 20 are iterated to provide a latestestimate of the pore pressure line and the associated uncertainty.

It can be appreciated that the method 20 can be performed using morethan one pore pressure related log and that a combined statisticalanalysis can be performed on all pluralities of trendlines establishedfrom each log. In addition, the pore pressure line (e.g., the averagepore pressure line) and its associated uncertainty can be calculatedfrom these pluralities of trendlines.

It can be appreciated that trendlines can be established by linearregression of all measurement points in the upper and lower depthintervals in lieu of a selection of only one measurement point in eachinterval to establish a trendline. As the depth intervals are shifted orwidened and more formation measurement points are obtained, a pluralityof trendlines are established and used to determine the pore pressureline and the associated uncertainty.

It can be appreciated that the pore pressure related logs for the use inthe method 20 can be obtained from boreholes different from the boreholebeing drilled (e.g., offset boreholes or wells). In real time LWDapplications, the analysis of trendlines can be performed on porepressure related logs from offset wells, for instance onporosity-indicating logs from the target borehole being drilled. If thepore pressure related logs originate from different locations, aweighting function may be applied to the derived trendlines in order torepresent the transferability of characteristics between the locationsof the boreholes wherein the logs were acquired.

In one or more embodiments, the method 20 can include a step foridentifying the presence of shale such as with a gamma-ray log forexample and for filtering out those pore pressure related measurementsperformed on non-shale portions of the formation.

Disclosed next is a method for estimating pore pressure uncertainty inthe overpressure region of an earth formation from the uncertaintyobserved in the normal compaction interval above the overpressureregion. Already while drilling in a still normally pressured subsurfaceformation, the method is able to estimate the order of magnitude of theuncertainty associated with the pore pressure model in the overpressureregion using data obtained while drilling in a still normally pressuredsubsurface formation. Drilling operational procedures, such asdetermining a pressure window for drilling, can be developed accordingto this estimation.

The disclosed method uses a series of normal compaction trendlines,calculated as described above, and calculates a “trendline envelope” asthe upper and lower bounds within which the series of trendlines vary.Different methods can be used to define different trendline envelopes.Irrespective of the applied method for envelope definition, thetrendline envelope shows a continuous increase in trendline uncertaintywith depth in the overpressure zone. This increase is quantified bycalculating the depth-based derivative of the difference between the twotrendline bounds as a measure of the change in trendline envelope withdepth. Whereas this quantity has exclusively been derived from data inthe normal compaction zone, an empirical correlation between thisquantity and the magnitude of the pore pressure uncertainty in theoverpressure (undercompacted) region was observed from different datasets from Gulf of Mexico, Asia Pacific and North Sea basins.

Two different methods are introduced here to derive the uncertainty ofthe pore pressure model as a result of variations in the normalcompaction trendline: a statistical and a geometrical approach. Thestatistical approach calculates one pore pressure model using any ofEquations (1) through (6), for example, for each trendline of the seriesthat has been calculated by the linear regression, which likewiseresults in a series of n*m pore pressure models. This series is thenstatistically analyzed to derive an average pore pressure model and itsstandard deviation (±one sigma, see FIG. 4). Of course, a statisticallysound result requires a sufficient amount of trendlines and porepressure models in the series. This is achieved by setting the start andend intervals for linear regression in a way that a sufficient amount ofdata points reside in either of the two intervals, yielding a sufficientamount of trendlines and models. For example, at least 50 data pointsmay need to reside in either of the two intervals, yielding more than2500 trendlines and models.

The second proposed method extracts the two normal compaction trendlinesexhibiting the largest and smallest slopes, respectively, out of theseries of trendlines. These two trendlines are then used to calculatethe pore pressure models by using, for example, any of Equations (1)through (6).

An example for the trendline envelopes is shown in FIG. 7. The track inFIG. 7A shows a logarithmically scaled resistivity log, an averagenormal compaction trendline (NCTL) and the NCTL's±1 standard deviation.In this example, the normal compaction interval ends at around 900meter. Note that the NCTL's do not cross each other at ˜800 meter, henceonly the average normal compaction trendline is a straight line on asemi-logarithmic scale. The difference between the two envelopingtrendlines (NCTL±1 sigma) becomes larger with increasing depth, inparticular in the overpressure region below 900 meter. The track in FIG.7B shows the two extreme normal compaction trendlines with the maximumand minimum slopes, respectively. These two NCTL's cross each other at˜800 meter and behave linearly on the log 10 resistivity scale. Also thedifference between these two enveloping trendlines becomes larger withincreasing depth.

A quantification parameter or “Q factor” is defined describing theincreasing difference between the enveloping normal compactiontrendlines:

$\begin{matrix}{{Q:={\frac{}{z}\left( {\Delta \; R_{N}^{*}} \right)}},} & (7)\end{matrix}$

where d/dz is the derivative of ΔR*_(N) with depth z, and

ΔR*_(N)=log₁₀ R _(N) ^(u)−log₁₀ R _(N) ^(l)  (8)

describes the difference of the upper (R_(N) ^(u)) and lower (R_(N)^(l)) bounds of the normal compaction trendlines. Of course, Q can bedefined also for calculating the uncertainty propagation derived fromacoustic slowness data or other pore pressure related logs. The Q factoris thus a measure of how the normal compaction trendline envelopes willchange with depth, and how this change will affect the uncertaintyassociated with pore pressure. The Q factor can be used to compare theuncertainty resulting from different pore pressure related logs (such asacoustic logs and resistivity logs) within one well, and the Q factorcan also be used to compare the uncertainty resulting from the same porepressure related logs between different wells.

For the example data set presented in FIGS. 7A and 7B, the Q factor isshown in FIG. 7C for methods 1 and 2. For method 1, the Q factor beginswith a negative sign, continually increases and finally approaches aconstant value of 0.0003/m at greater depth. This asymptotic behaviorallows the specification of one value that is characteristic for theopening behavior of the trendline envelopes, and the asymptotic behaviorhas been observed on all test data sets that were available for thepresent investigation. Therefore, a q factor is disclosed:

q:=Q where Q(z)=constant value.  (9)

For method 2, the Q factor is constant for all depth, because thetrendline envelope is bound by two straight lines; hence the change inthe difference between these two is constant.

The q factor is expected to be different for resistivity and acousticlogs because acoustic logs generally show less variability/curvature. Astudy of the q factor behavior was performed on data sets from differentworld wide regions such as Asia Pacific, Gulf of Mexico, North Sea,Offshore Canada and Offshore South America as shown in FIGS. 8 and 9. Ingeneral, the q factor from resistivity data proved to be larger comparedto the q factor from acoustic data, and the resistivity q factor is alsomore scattered. As also expected, the q factor from method 2 is larger(FIG. 9) compared to method 1 (FIG. 8).

For locations where multiple wells were available, a comparison of the qfactor shows that data from the Gulf of Mexico exhibit the lowest qfactor magnitudes, Asia Pacific data sets exhibit intermediate, andNorth Sea data exhibit the highest q factors. This observation impliesthat the analysis of normal compaction trendline and pore pressureuncertainties should be performed on data sets from the same geologicalbasin.

A series of pore pressure curves PP_(i) can also be calculated from theseries of normal compaction trendlines R_(N) ^(i), applying Eaton'sequation, which is rewritten here for convenience as Equation (10):

$\begin{matrix}{{{PP}_{i} = {{OBG} - {\left( {{OBG} - {PP}_{N}} \right)\left( \frac{R_{0}}{R_{N}^{i}} \right)^{x}}}},} & (10)\end{matrix}$

where OBG is the overburden gradient (or lithostatic pressure), PP_(N)is the hydrostatic pore pressure under normal conditions (in the normalcompaction zone), R_(o) is the measured resistivity and x is the Eatonexponent. A similar equation exists for acoustic logs or other pressurerelated logs (see Equations (2)-(6) for example). The series of porepressure curves can then be used to determine an average pore pressureand associated uncertainties such as ±1 standard deviation. For thecalculated normal compaction trendline envelopes from FIG. 7, an examplefor the calculated pore pressure uncertainty is given in FIGS. 4 and 5for methods 1 and 2, respectively.

The pore pressure uncertainty U_(PP) is a nonlinear function of thetrendline envelopes, as determined from inserting the upper and lowerbound of normal compaction trendlines, R_(N) ^(u) and R_(N) ^(l), intoEaton's Equation (10):

$\begin{matrix}\begin{matrix}{U_{PP} = {{{PP}\left( R_{N}^{u} \right)} - {{PP}\left( R_{N}^{l} \right)}}} \\{= {\left( {{OBG} - {PP}_{N}} \right)R_{0}^{x}\frac{\left( R_{N}^{l} \right)^{x} - \left( R_{N}^{u} \right)^{x}}{\left( {R_{N}^{u}R_{N}^{l}} \right)^{x}}}}\end{matrix} & (11)\end{matrix}$

Accordingly, similar expressions can be derived from equations (2)-(6).The pore pressure uncertainty can thus be calculated while drilling inthe overpressure region and once porosity-indicating or other porepressure related logs (R₀ in this case) are available.

A prediction of U_(PP) from the q factor was found to be possible bycorrelating U_(PP) with the q factor for acoustic data or forresistivity data. U_(PP) was calculated using Eq. (10) for theoverpressure zone, and then depth-averaging PP and U_(PP) to obtain onerepresentative value for the pore pressure and its uncertainty withinthe overpressure zone. Division of U_(PP) by PP gives the relativedepth-averaged pore pressure uncertainty U_(rel)/(PP).

The pore pressure uncertainty may be calculated as the depth-averageduncertainty of pore pressure uncertainties within the overpressure zoneas in Equation (12).

U _(abs)(PP)= PP(R_(N) ^(u))−PP(R_(N) ^(l)) PP(R_(N) ^(u))−PP(R_(N)^(l))  (12)

Equation (12) may then be used to calculate the relative depth-basedpore pressure uncertainty as in Equation (13) with PP being thedepth-averaged pore pressure.

$\begin{matrix}{{U_{rel}({PP})} = \frac{U_{abs}({PP})}{\overset{\_}{PP}}} & (13)\end{matrix}$

The correlation between q and U_(rel)(PP) was conducted on the threemulti-well data sets from the Asia Pacific region, the Gulf of Mexico,and the North Sea, both on acoustic and resistivity logs, respectively.For the data from the Asia Pacific region, FIGS. 10 and 11 show thecorrelations for acoustic and resistivity logs derived for methods 1 and2. The acoustic data (FIG. 10) clearly show a correlation between U_(PP)and q: larger q factors denote higher pore pressure uncertainty in theoverpressure zone. This correlation is also evident in the resistivitydata of FIG. 11.

A similar observation is made on acoustic data (FIG. 12) and resistivitydata (FIG. 13) from the Gulf of Mexico. Finally, the acoustic data fromthe North Sea (FIG. 14) show a very clear correlation between theuncertainty and the q factor.

Potential reasons for a poor correlation between the q factor and thepore pressure uncertainty are inadequately processed data (noenvironmental corrections applied to resistivity logs), short normallycompacted intervals for automatic analysis, geological circumstances(such as shallow water flows, structural features, salt) whichcomplicate the interpretation of porosity-indicating or other porepressure related logs, and improper application of the automationalgorithm. The latter one requires some experience of the users of thealgorithms. For example, a sufficiently large section of the normalcompaction zone should be covered by the start and end intervals toincorporate geometric variances in the log (for further calculations).In addition, the number of data points in the intervals must besufficient to ensure a statistically relevant number of trendlines.

The disclosed method is thus applicable for data from similar wells atleast within one region (such as the Gulf of Mexico) and requires asufficiently large number of drilled wells so that the correlationbetween the q factor and U_(PP) can be derived. The method can then beapplied to newly drilled wells by calculating the q factor and comparingthe q factor against the q factors from the existing wells.

A highly beneficial feature of a real-time wellbore stability model isto predict the uncertainty associated with a pore pressure model in theoverpressure zone by parameters acquired still in the normally compactedzone, which this disclosure covers in detail. If a sufficient amount ofwells has been drilled in a specific region so that a correlationbetween the pore pressure uncertainty and the q factor can be derived,then a real-time (while drilling) application as illustrated by the flowchart in FIG. 15 may be implemented.

While drilling through the normal compaction zone and running areal-time pore pressure model (i.e., modeling pore pressure during thedrilling operation on real-time streaming porosity-indicating or otherpore pressure related logs and other relevant data), the onset of theoverpressure zone is monitored. Once reaching the overpressure zone, theQ or q factor can be calculated and an expected uncertainty associatedwith the pore pressure model in the overpressure zone can be predicted.Also the uncertainty of the entire pressure window (fracture gradient,collapse gradient which both use the pore pressure gradient as inputparameter) caused by pore pressure uncertainty can be estimated and anoperating margin be defined around the pressure window bounds. Thisestimation of the operating margin is beneficial because the calculationof pore pressure uncertainty is based on formation evaluation sensorssome meters behind the bit in addition to the accuracy of the sensors.Further, the operating margin can take into account the accuracy ofequipment (such a pumps and valves) required to establish a desireddrilling fluid or mud flow rate for dynamic pressure reasons, which canaffect the downhole borehole pressure at the drill bit. Finally, thedrilling conditions such as the mud weight and flow rate can be set tofit within the operating margins, and drilling into the overpressurezone can continue.

FIG. 15 is a flow chart for an exemplary method 150 for drilling aborehole in an earth formation having a normal compaction zone and anoverpressure zone below the normal compaction zone. Included in themethod 150 is a method for predicting a pressure window for drilling theborehole. Block 151 calls for drilling the borehole within the normalcompaction zone with hydrostatic pore pressure distribution using adrilling tool. The drilling tool may include a drill tubular and anycutting tool such as a drill bit. Block 152 calls for obtaining a porepressure related log using a data acquisition tool, which may be adownhole tool or a surface tool such as a seismic data acquisition tool.The downhole tool may include at least one of resistivity tool, adielectric permittivity tool, a density tool, a neutron porosity tool, apulsed neutron tool, a nuclear magnetic resonance tool, and an acoustictool in non-limiting embodiments. Block 153 calls for reaching atransition depth in the borehole from the normal compaction zone to theoverpressure zone using the drilling tool and identifying the transitiondepth from the pore pressure related log using a processor. Thetransition depth may be identified by the one or more pore pressurerelated logs. The processor may be included in downhole electronics orin a surface processing system in non-limiting embodiments.

Block 154 calls for calculating pore pressure uncertainty in theoverpressure zone from the pore pressure related log in the normalcompaction zone using the processor. Alternatively, the pore pressureuncertainty may be calculated from a pore pressure related data value,which may be obtained from the pore pressure related log. The porepressure related log or data value may also be obtained from a dataacquisition tool, which may be the downhole tool or the surface dataacquisition tool. The pore pressure uncertainty may be calculated byinputting the pore pressure related log data and pore pressureindicating values relating to the normal compaction trendline into apore pressure model (e.g., Eq. (1)-(6)). The deviation of the porepressure calculated using the actual pore pressure related log data fromthe pore pressure calculated using pore pressure indicating valuescorresponding to the normal compaction trendline provides a measure ofthe uncertainty. Data from two or more previously drilled boreholes maybe used to generate a curve relating pore pressure uncertainty toq-factor. At least two previously drilled boreholes will provide aminimum level of assurance that the data is applicable to the formationbeing currently drilled. In a previously drilled borehole, the q-factoris calculated from data from a porosity-indicating log using Methods 1or 2 for example. In one or more embodiments, a straight line may bedrawn through two or more data points obtained from data from two ormore previously drilled boreholes. In one or more embodiments, amathematical function, such as a polynomial, may be used to generate acurve relating uncertainty to q-factor. Hence, once a q-factor iscalculated for a borehole being presently drilled, an associated porepressure uncertainty can be determined using the identified correlation.

Block 155 calls for estimating uncertainty of a pressure window fordrilling fluid using the calculated pore pressure uncertainty andapplying the estimated uncertainty to the pressure window to provide amodified (e.g., reduced) pressure window that accounts for pore pressureuncertainty using the processor.

Block 156 calls for defining an operating margin and applying theoperating margin to the modified pressure window to provide an operatingpressure window. The operating margin relates to the distance or marginbetween the modified drilling pressure window due to pore pressureuncertainty and the operating drilling pressure window that a drillingoperator desires to maintain in order to remain within the bounds of themodified drilling pressure window. In one or more embodiments,instrument uncertainty and equipment uncertainty (e.g., pump speed, pumpoutput pressure, and valve position) are used to determine the marginsbetween the drilling pressure window and the operating pressure window.Additional margins may be added to account for unknown factors. Bydrilling within the operating drilling pressure window (and thus withinthe modified drilling pressure window due to pore pressure uncertainty),the drilling operator has assurance that the drilling operation will bemaintained within the drilling pressure window.

Block 157 calls for defining a drilling parameter for drilling withinthe operating pressure window. In one or more embodiments, the drillingparameters include drilling fluid weight or density, drilling fluid pumpspeed, drilling fluid pump output pressure, drilling fluid outlet valveposition, a drilling fluid flow rate, an equivalent circulating drillingfluid density, an equivalent static drilling fluid density, and/or astandpipe pressure. And, block 158 calls for drilling into theoverpressure zone using the operating pressure window for the drillingfluid. The pressure of the drilling fluid in the borehole annulusdownhole is controlled to be within the operating pressure window. Inone or more embodiments, the computer processing system 12 is acontroller that maintains the pressure of the drilling fluid within theoperating pressure window by controlling the drilling fluid pump and/orthe drilling fluid flow control valve.

The method 150 may also include monitoring pore pressure to verify thepredicted pore pressure uncertainty. If the pore pressure exceeds theuncertainty bounds, then the drilling pressure window and subsequentlythe operating pressure window can be modified or reduced further toaccount for the increased uncertainty. The pore pressure can bemonitored by the porosity-indicating logs and a model relating porosityto pore pressure or by performing a formation pressure test using aprobe (not shown) that seals to a wall of the borehole to measure theformation pressure or other pore pressure related measurements.

The method 150 may include determining at least one pore pressurerelated trendline using the pore pressure related data value andextrapolating the at least one pore pressure related trendline.Determining here is meant to include calculating, plotting, and/orestimating. The trendline here may include the trendline of the porepressure related log.

The method 150 may include deriving a representative pore pressurerelated trendline from the at least one pore pressure related trendline.The representative pore pressure related trendline may be an average, amost frequently measured value, characteristic value (e.g., average) ofdata interval the measure data falls into.

The method 150 may include monitoring at least one equivalent ofdrilling fluid pressure and determining if the monitored drilling fluidpressure equivalent is within equivalents of an upper bound and a lowerbound of the operating pressure window. Equivalents of drilling fluidpressure may include equivalent static density of the drilling fluid,equivalent circulating density of the drilling fluid, and equivalentdrilling fluid weight.

In the method 150, the pore pressure uncertainty may account for atleast one of instrument error, equipment calibration error, statisticalerror of measurement apparatus or method, regression error of trendlineswhen the trendline comprises a plurality of trendlines, and variation oftrendlines when the trendline comprises a plurality of trendlines.

In the method 150, the pressure window may be defined at least in partby a fracture gradient, a pore pressure gradient, and a collapsegradient and the pore pressure uncertainty affects at least partly oneof the fracture gradient and the collapse gradient.

In support of the teachings herein, various analysis components may beused, including a digital and/or an analog system. For example, thedownhole electronic unit 11, the surface computer processing 12, or thedownhole tool 10 may include the digital and/or analog system. Thesystem may have components such as a processor, storage media, memory,input, output, communications link (wired, wireless, pulsed mud, opticalor other), user interfaces, software programs, signal processors(digital or analog) and other such components (such as resistors,capacitors, inductors and others) to provide for operation and analysesof the apparatus and methods disclosed herein in any of several mannerswell-appreciated in the art. It is considered that these teachings maybe, but need not be, implemented in conjunction with a set of computerexecutable instructions stored on a non-transitory computer readablemedium, including memory (ROMs, RAMs), optical (CD-ROMs), or magnetic(disks, hard drives), or any other type that when executed causes acomputer to implement the method of the present invention. Theseinstructions may provide for equipment operation, control, datacollection and analysis and other functions deemed relevant by a systemdesigner, owner, user or other such personnel, in addition to thefunctions described in this disclosure.

Further, various other components may be included and called upon forproviding for aspects of the teachings herein. For example, a powersupply (e.g., at least one of a generator, a remote supply and abattery), cooling component, heating component, magnet, electromagnet,sensor, electrode, transmitter, receiver, transceiver, antenna,controller, optical unit, electrical unit or electromechanical unit maybe included in support of the various aspects discussed herein or insupport of other functions beyond this disclosure.

Elements of the embodiments have been introduced with either thearticles “a” or “an.” The articles are intended to mean that there areone or more of the elements. The terms “including” and “having” areintended to be inclusive such that there may be additional elementsother than the elements listed. The conjunction “or” when used with alist of at least two terms is intended to mean any term or combinationof terms. The terms “first” and “second” are used to distinguishelements and are not used to denote a particular order. The term“couple” relates to coupling a first component to a second componenteither directly or indirectly through an intermediate component.

It will be recognized that the various components or technologies mayprovide certain necessary or beneficial functionality or features.Accordingly, these functions and features as may be needed in support ofthe appended claims and variations thereof, are recognized as beinginherently included as a part of the teachings herein and a part of theinvention disclosed.

While the invention has been described with reference to exemplaryembodiments, it will be understood that various changes may be made andequivalents may be substituted for elements thereof without departingfrom the scope of the invention. In addition, many modifications will beappreciated to adapt a particular instrument, situation or material tothe teachings of the invention without departing from the essentialscope thereof. Therefore, it is intended that the invention not belimited to the particular embodiment disclosed as the best modecontemplated for carrying out this invention, but that the inventionwill include all embodiments falling within the scope of the appendedclaims.

What is claimed is:
 1. A method for predicting a pressure window fordrilling a borehole in a formation, the method comprising: obtaining apore pressure related data value of the formation using a dataacquisition tool; predicting pore pressure uncertainty from the porepressure related data value of the formation using a processor;estimating uncertainty of a pressure window for drilling fluid using thepredicted pore pressure uncertainty using a processor; and applying theestimated uncertainty to the pressure window to provide a modifiedpressure window using a processor.
 2. The method according to claim 1,further comprising defining an operating margin and applying theoperating margin to the modified pressure window to provide an operatingpressure window using a processor.
 3. The method according to claim 2,further comprising monitoring at least one equivalent of drilling fluidpressure and determining if the monitored drilling fluid pressureequivalent is within equivalents of an upper bound and a lower bound ofthe operating pressure window.
 4. The method according to claim 2,further comprising: defining a drilling parameter for drilling aborehole in the formation within the operating pressure window using aprocessor; and drilling into the formation using a drilling tool and theoperating pressure window for the drilling fluid.
 5. The methodaccording to claim 4, wherein the drilling parameter comprises at leastone of a drilling fluid density, a drilling fluid flow rate, anequivalent circulating drilling fluid density, an equivalent staticdrilling fluid density, and a standpipe pressure.
 6. The methodaccording to claim 1, further comprising determining at least one porepressure related trendline using the pore pressure related data valueand extrapolating the at least one pore pressure related trendline. 7.The method according to claim 6, wherein the pore pressure related valueis obtained from a pore pressure related log acquired by the dataacquisition tool.
 8. The method according to claim 6, wherein theformation comprises a normal compaction zone and an overpressure zonebelow the normal compaction zone and method further comprisesdetermining the at least one pore pressure related trendline from datafrom the normal compaction zone and extrapolating the at least one porepressure related trendline into the overpressure zone.
 9. The methodaccording to claim 6, wherein the pore pressure uncertainty accounts forat least one selection from a group consisting of instrument error,equipment calibration error, statistical error of measurement apparatusor method, regression error of trendlines when the trendline comprises aplurality of trendlines, and variation of trendlines when the trendlinecomprises a plurality of trendlines.
 10. The method according to claim9, further comprising identifying a correlation between pore pressureuncertainty and the uncertainty of the pore pressure related data valueusing data from at least two previously drilled boreholes and whereincalculating the pore pressure uncertainty further comprises using theuncertainty of the pore pressure related data value and the correlation.11. The method according to claim 6, further comprising deriving arepresentative pore pressure related trendline from the at least onepore pressure related trendline.
 12. The method according to claim 6,wherein the at least one pore pressure related trendline comprises aplurality of pore pressure related trendlines and the method furthercomprising determining an upper bound line having an upper bound lineslope and a lower bound line having a lower bound line slope, whereinthe upper bound line slope is less than a slope of the plurality of porepressure related trendlines and the slope of the plurality of porepressure related trendlines is less than the lower bound line slope, theupper bound line indicating positive uncertainty with respect to thepore pressure related trendline and the lower bound line indicatingnegative uncertainty with respect to the pore pressure relatedtrendline.
 13. The method according to claim 12, wherein the upper boundline is a function of an uncertainty of the plurality of pore pressuretrendlines and the lower bound line is a function of an uncertainty ofthe plurality of pore pressure trendlines.
 14. The method according toclaim 6, wherein the at least one pore pressure related trendlinecomprises a plurality of pore pressure related trendlines and the methodfurther comprising determining an upper bound line having an upper boundline slope and a lower bound line having a lower bound line slope,wherein the upper bound line is a pore pressure related trendline in theplurality of pore pressure related trendlines having a minimum slope andthe lower bound line is a pore pressure line in the plurality of porepressure related trendlines having a maximum slope.
 15. The methodaccording to claim 1, wherein calculating pore pressure uncertainty inthe overpressure zone comprises calculating a Q-factor by solving:${Q = {\frac{}{z}\left( {\Delta \; R_{N}^{*}} \right)}},$ whered/dz is the derivative of ΔR*_(N) with depth z, andΔR*_(N)=log₁₀ R _(N) ^(u)−log₁₀ R _(N) ^(l) represents the differencebetween the upper (R_(N) ^(u)) and lower (R_(N) ^(l)) bounds at depth zthat envelope an estimate of a pore pressure related value.
 16. Themethod according to claim 15, wherein Q=constant value q.
 17. The methodaccording to claim 1, wherein the pressure window is defined at least inpart by a fracture gradient, a pore pressure gradient, and a collapsegradient and the pore pressure uncertainty affects at least partly oneof the fracture gradient and the collapse gradient.
 18. An apparatus forpredicting a pore pressure window for drilling a borehole in aformation, the apparatus comprising: a data acquisition tool configuredto perform formation measurements related to pore pressure of theformation at a plurality of depths in the borehole; and a processor incommunication with the downhole tool and configured to implement amethod comprising at least one of the steps: obtaining a pore pressurerelated data value of the formation from the data acquisition tool;predicting pore pressure uncertainty from the pore pressure related datavalue of the formation; estimating uncertainty of a pressure window fordrilling fluid using the predicted pore pressure uncertainty; andapplying the estimated uncertainty to the pressure window to provide amodified pressure window.
 19. The apparatus according to claim 18,wherein the processor is further configured to: define an operatingmargin and apply the operating margin to the modified pressure window toprovide an operating pressure window; and define a drilling parameterfor drilling a borehole in the formation within the operating pressurewindow.
 20. The apparatus according to claim 19, further comprising adrilling tool configured to drill the borehole within the operatingpressure window.
 21. The apparatus according to claim 19, furthercomprising a controller configured to control a drilling fluid pump or adrilling fluid control valve to maintain drilling fluid pressureequivalent within the operating pressure window.
 22. The apparatusaccording to claim 19, further comprising a controller configured tocontrol a drilling fluid flow control valve to maintain drilling fluidpressure within the operating pressure window.
 23. The apparatusaccording to claim 19, further comprising a drilling fluid sensorconfigured to sense a drilling fluid parameter and to provide input to acontroller configured to provide an output to maintain drilling fluidpressure within the operating pressure window.
 24. The apparatusaccording to claim 18, wherein the data acquisition tool comprises adownhole tool comprising at least one of a gamma ray tool, a resistivitytool, a dielectric permittivity tool, a density tool, a neutron porositytool, a pulsed neutron tool, a nuclear magnetic resonance tool, and anacoustic tool.
 25. The apparatus according to claim 18, wherein the dataacquisition tool is configured to acquire formation data at the surfaceof the formation.